GeoPark Reports Third Quarter 2020 Results

Rhea-AI Summary

GeoPark Limited (NYSE: GPRK) reported its 3Q2020 financial results, posting consolidated revenue of $98.1 million, a 35% decline from $151.2 million in 3Q2019. Oil production averaged 38,845 boepd, marking a 5% increase from the previous quarter, while operating costs per boe decreased by 22% to $6.3. The net loss stood at $4.3 million. GeoPark aims for annual production of 40,000-42,000 boepd in 2021, supported by a reduction in capital expenditures by 56% to $9.8 million, alongside strategic cost-cutting measures.

Positive

• Production increased by 5% to 38,845 boepd from the previous quarter.
• Operating costs per boe decreased by 22% to $6.3.
• Achieved adjusted EBITDA of $56.1 million, a 2x increase from the previous quarter.
• Implemented cost and investment reductions totaling over $290 million.
• Plans for annual production of 40,000-42,000 boepd in 2021.

Negative

• Consolidated revenue declined by 35% from $151.2 million in 3Q2019 to $98.1 million in 3Q2020.
• Reported a net loss of $4.3 million compared to a profit of $6.8 million in 3Q2019.
• Realized oil price decreased by 36% to $31.7 per bbl due to lower Brent prices.

BOGOTA, Colombia--(BUSINESS WIRE)--GeoPark Limited (“GeoPark” or the “Company”) (NYSE: GPRK), a leading independent Latin American oil and gas explorer, operator and consolidator with operations and growth platforms in Colombia, Peru, Argentina, Brazil, Chile and Ecuador reports its consolidated financial results for the three-month period ended September 30, 2020 (“Third Quarter” or “3Q2020”). A conference call to discuss 3Q2020 financial results and the work program and investment guidelines for 2021 will be held on November 5, 2020 at 10:00 am (Eastern Standard Time).

All figures are expressed in US Dollars and growth comparisons refer to the same period of the prior year, except when specified. Definitions and terms used herein are provided in the Glossary at the end of this document. This release does not contain all of the Company’s financial information and should be read in conjunction with GeoPark’s consolidated financial statements and the notes to those statements for the period ended September 30, 2020 and 2019, available on the Company’s website.

THIRD QUARTER 2020 HIGHLIGHTS

Expanded Production and Restarted Work Program

• Consolidated oil and gas production of 38,845 boepd in 3Q2020, up 5% compared to 2Q2020
• Resumed drilling with three wells put on production in the Llanos 34 block (GeoPark operated, 45% WI)
• Reopened temporarily shut-in production and producing 40,000 boepd by the end of 3Q2020
• Currently drilling the Indico 2 appraisal well in the CPO-5 block (GeoPark non-operated, 30% WI)

Implemented Decisive Cost and Investment Reduction Plan

• Cost and investment reductions totaled over $290 million across regional platform
• Further improving GeoPark’s cost efficiencies with ongoing cost-cutting initiatives at all levels
• Production and operating costs reduced by 32% to $28.4 million
• Operating costs per boe¹ reduced by 22% to $6.3 per boe
• G&A/G&G costs reduced by 30% to $13.1 million

Generated Substantial Free Cash Flow

• Revenue of $98.1 million
• Adjusted EBITDA of $56.1 million (or $15.9 per boe), 2x Adjusted EBITDA in 2Q2020
• Operating Profit of $28.5 million / Net Loss of $4.3 million
• Capital expenditures reduced by 56% to $9.8 million
• Full-year 2020 work program of $65-75 million targeting 40,000-42,000 boepd annual average production and operating netbacks of $245-270 million assuming Brent of $35-40 per bbl²

Built Strong Financial Position and Risk Management

• $163.7 million cash ($157.5 million in 2Q2020 and after interest payments of $23.5 million in 3Q2020)
• $75 million oil prepayment facility, with $50 million committed and no amounts drawn
• $132.9 million in uncommitted credit lines
• Long-term financial debt maturity profile with no principal payments until September 2024
• Continuously adding new hedges for the next 15 months

Increased SPEED/ESG+ Response and Actions

• Protocols, preventive measures and crisis response plans in place across six-country regional platform
• Field teams sharply reduced to a minimum with back-up teams and contingencies in place to keep people working safely and production flowing
• GeoPark closely engaged with local communities implementing a significant range of measures to fight Covid-19 with efforts coordinated at local, regional and federal levels
• Appointment of Sylvia Escovar and Somit Varma as new independent members of GeoPark’s Board of Directors (filling vacancies)
• Released GeoPark's Environmental, Social and Governance ("ESG") report for 2019, available on the Company's website

Returning Value to Shareholders by Cash Dividends and Share Buyback Program

• 2020 Extraordinary Cash Dividend of $0.0206 per share ($1.25 million) payable on December 9, 2020
• 2020 Quarterly Dividend of $0.0206 per share ($1.25 million) payable on December 9, 2020
• Resuming discretionary share buyback program for up to 10% of total outstanding shares

James F. Park, Chief Executive Officer of GeoPark, said: “Thanks to and admiration for the GeoPark team for again performing through this monster storm. Because of its quick, decisive and significant moves, GeoPark today is in a position to re-engage our work program, grow production, build and set into motion an attractive work program for 2021 and begin returning cash to its shareholders in the fourth quarter. And, beyond just surviving the collapse and accommodating to the new environment, our team transformed GeoPark – from a cost, capability, and organizational perspective – into a better and stronger company ready to capture the immense opportunity ahead.”

CONSOLIDATED OPERATING PERFORMANCE

Key performance indicators:

Key Indicators		3Q2020		2Q2020		3Q2019		9M2020		9M2019
Oil productiona (bopd)		32,875		32,504		33,693		35,404		34,102
Gas production (mcfpd)		35,814		26,448		35,555		30,509		32,148
Average net production (boepd)		38,845		36,912		39,619		40,490		39,460
Brent oil price ($ per bbl)		43.3		33.1		62.1		42.5		64.7
Combined realized price ($ per boe)		27.9		17.8		44.2		27.3		46.4
⁻ Oil ($ per bbl)		31.7		18.6		49.3		29.8		51.3
⁻ Gas ($ per mcf)		2.5		2.8		4.4		3.0		4.6
Sale of crude oil ($ million)		89.3		49.0		138.2		262.2		434.6
Sale of gas ($ million)		8.8		6.6		13.0		24.9		36.2
Revenue ($ million)		98.1		55.7		151.2		287.0		470.9
Commodity risk management contracts ($ million)		2.7		-9.1		4.4		25.6		-16.0
Production & operating costsb ($ million)		-28.4		-20.7		-41.7		-90.2		-126.7
G&G, G&AC and selling expenses ($ million)		-14.4		-15.9		-21.1		-49.4		-63.7
Adjusted EBITDA ($ million)		56.1		27.8		86.7		161.6		277.7
Adjusted EBITDA ($ per boe)		15.9		8.9		25.3		15.3		27.4
Operating Netback ($ per boe)		19.2		13.0		31.4		19.2		33.0
Net Profit (loss) ($ million)		-4.3		-19.9		6.8		-113.7		57.9
Capital expenditures ($ million)		9.8		5.8		22.1		49.3		88.2
Amerisur acquisitiond ($ million)		-		-		-		272.3		-
Cash and cash equivalents ($ million)		163.7		157.5		81.6		163.7		81.6
Short-term financial debt ($ million)		4.8		19.9		10.6		4.8		10.6
Long-term financial debt ($ million)		767.4		763.5		424.4		767.4		424.4
Net debt ($ million)		608.4		625.9		353.4		608.4		353.4

a) Includes royalties paid in kind in Colombia for approximately 1,284, 1,286 and 1,419 bopd in 3Q2020, 2Q2020 and 3Q2019 respectively. No royalties were paid in kind in Chile, Brazil or Argentina.

b) Production and operating costs include operating costs and royalties paid in cash.

c) G&A and G&G expenses include non-cash, share-based payments for $1.8 million, $2.0 million and $0.3 million in 3Q2020, 2Q2020 and 3Q2019, respectively. These expenses are excluded from the Adjusted EBITDA calculation.

d) Amerisur acquisition is shown net of cash acquired.

Production: Overall oil and gas production decreased by 2% to 38,845 boepd in 3Q2020 from 39,619 boepd in 3Q2019, due to reopened shut-in production and limited drilling and maintenance activities during the quarter, partially offset by the addition of production from the recent Amerisur Resources Plc (“Amerisur”) acquisition in Colombia. Oil represented 85% of total reported production in 3Q2020 and 3Q2019.

For further details, please refer to the 3Q2020 Operational Update published on October 14, 2020.

Reference and Realized Oil Prices: Brent crude oil prices averaged $43.3 per bbl during 3Q2020, $18.6 per bbl lower than 3Q2019 levels. Consolidated realized oil sales price averaged $31.7 per bbl in 3Q2020, $17.6 per bbl lower than the $49.3 per bbl in 3Q2019, reflecting a higher local marker differential in Colombia that was partially offset by lower commercial and transportation discounts.

In Colombia, the local marker differential to Brent averaged $3.0 per bbl in 3Q2020, compared to $6.5 per bbl in 2Q2020 and $1.7 per bbl in 3Q2019. Commercial and transportation discounts improved by $2.1 per bbl and averaged $9.0 per bbl in 3Q2020, compared to $11.1 per bbl in 3Q2019, resulting from further improvements achieved for production in the Llanos 34 block plus the addition of the Platanillo (GeoPark operated, 100% WI) and CPO-5 blocks as part of the Amerisur acquisition, both of which have lower commercial and transportation discounts.

The tables below provide a breakdown of reference and net realized oil prices in Colombia, Chile and Argentina in 3Q2020 and 3Q2019:

3Q2020 - Realized Oil Prices ($ per bbl)	Colombia	Chile	Argentina
Brent oil price (*)	43.3	42.7	43.3
Local marker differential	(3.0)	-	-
Commercial and transportation discounts	(9.0)	(7.7)	-
Other	-	-	(2.8)
Realized oil price	31.3	35.0	40.5
Weight on oil sales mix	94%	1%	5%

3Q2019 - Realized Oil Prices ($ per bbl)	Colombia	Chile	Argentina
Brent oil price (*)	62.1	62.0	62.1
Local marker differential	(1.7)	-	-
Commercial and transportation discounts	(11.1)	(7.7)	-
Other	-	-	(13.2)
Realized oil price	49.3	54.3	48.9
Weight on oil sales mix	94%	1%	5%

(*) Specified Brent oil price differs in each country as sales in Colombia are priced with reference to ICE Brent whereas sales in Chile are priced with reference to Dated Brent. In Argentina, local prices are dissociated from international oil prices and differences between international benchmarks and realized prices are included in “Other”.

Revenue: Consolidated revenue decreased by 35% to $98.1 million in 3Q2020, compared to $151.2 million in 3Q2019 reflecting lower oil and gas prices.

Sales of crude oil: Consolidated oil revenue decreased by 35% to $89.3 million in 3Q2020, driven by a 36% decrease in realized oil prices and flat deliveries. Oil revenue was 91% of total revenue in 3Q2020 and 3Q2019.

• Colombia: In 3Q2020, oil revenue decreased by 36% to $82.8 million reflecting lower realized oil prices and a 1% increase in oil deliveries. Realized prices decreased by 36% to $31.3 per bbl due to lower Brent oil prices and a higher Vasconia differential, partially compensated by lower commercial and transportation discounts. Oil deliveries increased by 1% to 29,962 bopd, reflecting the recent acquisition of Amerisur that was partially offset by temporary shut-ins and limited drilling and maintenance activity. Colombian earn-out payments decreased by 42% to $3.4 million in 3Q2020, compared to $6.0 million in 3Q2019, in line with lower oil revenue in the Llanos 34 block.
• Chile: In 3Q2020, oil revenue decreased by 49% to $1.2 million, due to lower oil prices and volumes sold. Realized oil prices decreased by 36% to $35.0 per bbl, in line with lower Brent prices. Oil deliveries decreased by 21% to 361 bopd due to limited maintenance works and no drilling activity, combined with the natural decline of the fields.
• Argentina: In 3Q2020, oil revenue decreased by 21% to $5.3 million due to lower oil prices and to a lesser extent, lower deliveries. Realized oil prices decreased by 17% to $40.5 per bbl due to the dissociation of local oil prices from international oil prices whereas oil deliveries decreased by 4% to 1,424 bopd due to limited maintenance works and no drilling activity, combined with the natural decline of the fields.

Sales of gas: Consolidated gas revenue decreased by 32% to $8.8 million in 3Q2020 compared to $13.0 million in 3Q2019 reflecting 43% lower gas prices, partially offset by a 19% increase in volumes delivered. Gas revenue was 9% of total revenue in both 3Q2020 and 3Q2019.

• Chile: In 3Q2020, gas revenue decreased by 28% to $4.2 million reflecting lower gas prices, partially offset by higher gas deliveries. Gas prices were 42% lower, or $2.3 per mcf ($14.1 per boe) in 3Q2020 due to lower methanol prices. The successful development of the Jauke gas field and the recent discovery of the Jauke Oeste gas field in early 2020 increased gas deliveries by 25% to 19,374 mcfpd (3,229 boepd).
• Brazil: In 3Q2020, gas revenue decreased by 42% to $3.3 million, due to lower gas deliveries and lower gas prices. Gas deliveries fell by 30% in the Manati gas field (GeoPark non-operated, 10% WI) to 8,661 mcfpd (1,443 boepd) due to lower gas demand in Brazil. Gas prices decreased by 16% to $4.1 per mcf ($24.8 per boe), due to the impact of the local currency devaluation, which was partially offset by the annual price inflation adjustment of approximately 7%, effective in January 2020.
• Argentina: In 3Q2020, gas revenue decreased by 15% to $0.8 million, resulting from lower gas prices, partially offset by higher deliveries. Gas prices decreased by 28% to $2.1 per mcf ($12.4 per boe) due to local market conditions while deliveries increased by 18% to 4,320 mcfpd (720 boepd) due to optimization activities focused on enhancing base production levels and the improved performance of the Challaco Bajo gas field.

Commodity Risk Management Contracts: Consolidated commodity risk management contracts amounted to a $2.7 million gain in 3Q2020, compared to a $4.4 million gain in 3Q2019.

Commodity risk management contracts have two different components, a realized and an unrealized portion.

The realized portion of the commodity risk management contracts registered a cash gain of $1.4 million in both 3Q2020 and 3Q2019. Realized gains in 3Q2020 resulted from hedges in place providing protection to prevailing oil prices during 3Q2020.

The unrealized portion of the commodity risk management contracts amounted to a $1.3 million gain in 3Q2020, compared to a $3.0 million gain in 3Q2019. Unrealized gains during 3Q2020 resulted from a slight decrease in the forward Brent oil price curve compared to June 2020 and the impact of new hedges added during 3Q2020 as measured at September 30, 2020.

GeoPark recently added new oil hedges further increasing its low-price risk protection over the next 15 months. Please refer to the “Commodity Risk Oil Management Contracts” section below for a description of hedges in place as of the date of this release.

Production and Operating Costs³: Consolidated production and operating costs decreased by 32% to $28.4 million from $41.7 million resulting from lower royalties and lower operating costs per boe.

The table below provides a breakdown of production and operating costs in 3Q2020 and 3Q2019:

(In millions of $)		3Q2020		3Q2019
Operating costs		19.9		26.6
Royalties		8.4		15.1
Share-based payments		0.1		-
Production and operating costs		28.4		41.7

Consolidated operating costs decreased by 25%, or $6.7 million to $19.9 million in 3Q2020 compared to $26.6 million in 3Q2019. Consolidated operating costs per boe decreased to $6.3 in 3Q2020 from $8.1 per boe in 3Q2019.The breakdown of operating costs is as follows:

• Colombia: Operating costs per boe increased by 5% to $5.9 in 3Q2020 compared to $5.6 in 3Q2019. Total operating costs remained flat and amounted to $15.2 million, due to the addition of the Platanillo block as part of the Amerisur acquisition, which has higher costs per boe than the Llanos 34 block, partially offset by ongoing cost reduction efforts and the effect of the devaluation of the local currency.
• Chile: Operating costs per boe decreased by 72% to $5.3 in 3Q2020 compared to $19.3 in 3Q2019, due to ongoing cost reduction efforts (including lower well intervention activities, efficiencies and the renegotiation of existing contracts) and to a lesser extent, to the devaluation of the local currency. Total operating costs decreased by 67% to $1.8 million in 3Q2020 from $5.4 million in 3Q2019, despite an increase of 18% in oil and gas deliveries.
• Brazil: Operating costs per boe decreased by 27% to $5.8 in 3Q2020 compared to $7.9 in 3Q2019 mainly reflecting the impact of the devaluation of the local currency. Total operating costs decreased by $0.7 million to $0.3 million in 3Q2020 compared to $1.0 million in 3Q2019, reflecting lower operating costs per boe and lower production and deliveries in Manati gas field, which decreased by 31%.
• Argentina: Operating costs per boe decreased by 45% to $14.9 in 3Q2020 compared to $27.0 in 3Q2019 due to ongoing cost reduction efforts (including lower well intervention activities, efficiencies and the renegotiation of existing contracts) and to a lesser extent, due to the devaluation of the local currency. Total operating costs decreased by 45% to $2.8 million in 3Q2020 compared to $4.9 million in 3Q2019 due to lower operating costs per boe, partially offset by a 2% increase oil and gas deliveries.

Consolidated royalties fell by 45% or $6.7 million to $8.4 million in 3Q2020 compared to $15.1 million in 3Q2019, mainly resulting from lower oil prices, partially offset by a 3% increase in oil and gas deliveries.

Selling Expenses: Consolidated selling expenses decreased by $1.1 million to $1.3 million in 3Q2020 (of which $0.8 million, or $0.3 per bbl, correspond to Colombia), compared to $2.4 million in 3Q2019.

Administrative Expenses: Consolidated G&A costs per boe decreased by 41% to $2.5⁴ in 3Q2020 compared to $4.2 in 3Q2019 due to ongoing cost reduction initiatives that even outweighed the incremental G&A costs related to the addition of Amerisur operations. Total consolidated G&A decreased by $4.1 million to $10.4 million in 3Q2020 compared to $14.5 million in 3Q2019.

Geological & Geophysical Expenses: Consolidated G&G costs per boe decreased by 56% to $0.8⁵ in 3Q2020 versus $1.8 in 3Q2019 due to ongoing cost reduction initiatives and despite incremental G&G costs related to the addition of Amerisur operations. Total consolidated G&G expenses decreased by $1.5 million to $2.8 million in 3Q2020 compared to $4.3 million in 3Q2019.

Adjusted EBITDA: Consolidated Adjusted EBITDA⁶ decreased by 35% to $56.1 million, or $15.9 per boe, in 3Q2020 compared to $86.7 million, or $25.3 per boe, in 3Q2019.

• Colombia: Adjusted EBITDA of $53.4 million in 3Q2020
• Chile: Adjusted EBITDA of $2.7 million in 3Q2020
• Brazil: Adjusted EBITDA of $1.9 million in 3Q2020
• Argentina: Adjusted EBITDA of $0.4 million in 3Q2020
• Corporate, Ecuador and Peru: Adjusted EBITDA of negative $2.2 million in 3Q2020

The table below shows production, volumes sold and the breakdown of the most significant components of Adjusted EBITDA for 3Q2020 and 3Q2019, on a per country and per boe basis:

Adjusted EBITDA/boe		Colombia					Chile					Brazil						Argentina					Total
		3Q20			3Q19		3Q20			3Q19		3Q20			3Q19			3Q20			3Q19		3Q20		3Q19
Production (boepd)		31,297			31,578		3,610			3,358		1,581			2,299			2,357			2,384		38,845		39,619
Inventories, RIKa & Other		(251)			(1,629)		(20)			(311)		(117)			(190)			(213)			(285)		(601)		(2,414)
Sales volume (boepd)		31,046			29,949		3,590			3,047		1,464			2,109			2,144			2,099		38,244		37,205
% Oil		96.5%			99.5%		10%			15%		1%			2%			66%			71%		83%		85%
($ per boe)
Realized oil price		31.3			49.3		35.0			54.3		40.6			69.2			40.5			48.9		31.7		49.3
Realized gas priceb		5.3			34.5		14.1			24.4		24.8			29.7			12.4			17.4		14.8		25.9
Earn-out		(1.2)			(2.2)		-			-		-			-			-			-		(1.0)		(1.7)
Combined Price		29.2			47.0		16.2			28.9		25.0			30.4			31.1			39.8		27.9		44.2
Realized commodity risk management contracts		0.5			0.5		-					-						-					0.4		0.4
Operating costs		(5.9)			(5.6)		(5.3)			(19.3)		(5.8)			(7.9)			(14.9)			(27.0)		(6.3)		(8.1)
Royalties in cash		(2.4)			(4.8)		(0.6)			(1.0)		(2.3)			(2.3)			(5.0)			(6.1)		(2.4)		(4.4)
Selling & other expenses		(0.3)			(0.7)		(0.2)			(0.3)		-			-			(2.2)			(1.3)		(0.4)		(0.7)
Operating Netback/boe		21.1			36.4		10.1			8.2		17.0			20.1			9.0			5.4		19.2		31.4
G&A, G&G & other																							(3.3)		(6.1)
Adjusted EBITDA/boe																							15.9		25.3

a) RIK (Royalties in kind). Includes royalties paid in kind in Colombia for approximately 1,284 and 1,419 bopd in 3Q2020 and 3Q2019 respectively. No royalties were paid in kind in Chile, Brazil or Argentina.

b) Conversion rate of $mcf/$boe=1/6.

Depreciation: Consolidated depreciation charges increased by 1% to $26.7 million in 3Q2020, compared to $26.5 million in 3Q2019, in line with a slight increase in volumes delivered.

Write-off of unsuccessful exploration efforts: The consolidated write-off of unsuccessful exploration efforts amounted to $0.6 million in 3Q2020 compared to $8.4 million in 3Q2019. Amounts recorded in 3Q2019 mainly refer to unsuccessful exploration wells and other exploration costs incurred in the CN-V (GeoPark non-operated, 50% WI) and Sierra del Nevado (GeoPark non-operated, 18% WI) blocks in Argentina.

Impairment of Non-Financial Assets: Consolidated non-cash impairment of non-financial assets amounted to $1.0 million in 3Q2020 and is related to the REC-T 128 block (GeoPark operated, 70% WI) in Brazil that was classified as an asset held for sale as of September 30, 2020. A non-cash impairment loss is recognized for the amount by which an asset’s carrying amount exceeds its recoverable amount.

Other Income (Expenses): Other operating expenses were $1.3 million in 3Q2020, compared to $1.4 million in 3Q2019.

CONSOLIDATED NON-OPERATING RESULTS AND PROFIT FOR THE PERIOD

Financial Expenses: Net financial expenses increased to $15.8 million in 3Q2020, compared to $8.6 million in 3Q2019 mainly resulting from higher interest expenses related to the issuance of $350 million notes due in 2027 (2027 Notes).

Foreign Exchange: Net foreign exchange charges added a $0.7 million loss in 3Q2020 compared to a $0.8 million gain in 3Q2019.

Income Tax: Income taxes totaled $16.3 million loss in 3Q2020 compared to $41.8 million loss in 3Q2019, mainly resulting from lower profits before income taxes and the effect of fluctuations of local currencies over deferred income taxes.

Profit: Loss of $4.3 million in 3Q2020 compared to a $6.8 million profit recorded in 3Q2019, mainly due to lower operating profits and higher financial expenses, partially offset by lower income taxes.

BALANCE SHEET

Cash and Cash Equivalents: Cash and cash equivalents totaled $163.7 million as of September 30, 2020 compared to $111.2 million as of December 31, 2019. Cash generated from operating activities equaled $91.6 million and cash generated from financing activities equaled $284.2 million, partially offset by cash used in investing activities of $321.6 million.

Cash generated from financing activities of $284.2 million mainly included net proceeds from the issuance of the 2027 Notes of $342.5 million, partially offset by interest payments of $37.5 million, lease payments of $7.3 million, $4.5 million related to the acquisition of the LG International Corp’s non-controlling interest in Colombia and Chile in 2018, short-term principal payments of $3.6 million and share repurchase payments of $3.0 million.

Cash used in investing activities of $321.6 million included the acquisition of Amerisur of $272.3 million (net of cash received), and organic capital expenditures of $49.3 million.

Financial Debt: Total financial debt net of issuance cost was $772.2 million, including the 2024 Notes, the 2027 Notes and other short-term bank loans totaling $3.5 million. Short-term financial debt was $4.8 million as of September 30, 2020.

For further details, please refer to Note 12 of GeoPark’s consolidated financial statements as of September 30, 2020, available on the Company’s website.

FINANCIAL RATIOS^a

(In millions of $)
Period-end		Financial Debt		Cash and Cash Equivalents		Net Debt		Net Debt/LTM Adj. EBITDA		LTM Interest Coverage
3Q2019		435.0		81.6		353.4		1.0x		12.1x
4Q2019		437.4		111.2		326.2		0.9x		12.1x
1Q2020		775.3		165.5		609.9		1.7x		11.6x
2Q2020		783.4		157.5		625.9		2.3x		7.2x
3Q2020		772.2		163.7		608.4		2.5x		5.7x

a)

Based on trailing last twelve-month financial results (“LTM”).

Covenants in 2024 Notes: The 2024 Notes include incurrence test covenants that require the net debt to Adjusted EBITDA ratio to be lower than 3.25 times and the Adjusted EBITDA to interest ratio to be higher than 2.25 times until September 2021. As of the date of this release the Company is compliant with both covenants.

Issuance of 2027 Notes: In January 2020, the Company issued $350 million of 5.5% notes due in 2027 (2027 Notes) in accordance with Rule 144A under the United States Securities Act, and outside the United States to non-U.S. persons in accordance with Regulation S under the United States Securities Act. Funds were used for the Amerisur acquisition and for general corporate purposes. The indenture governing the 2027 Notes includes incurrence test covenants that provide, among other things, that Net Debt to Adjusted EBITDA ratio should not exceed 3.25 times and the Adjusted EBITDA to Interest ratio should exceed 2.5 times. As of the date of this release, the Company is well within both covenants.

For further details, please refer to Note 12 of GeoPark’s consolidated financial statements as of September 30, 2020, available on the Company’s website.

COMMODITY RISK OIL MANAGEMENT CONTRACTS

GeoPark recently added new oil hedges further increasing its price risk protection over the next 15 months, now reaching 25,500 bopd in 4Q2020, 15,500 bopd in 1Q2021, 13,000 bopd in 2Q2021, and 4,500 bopd in 2H2021. Hedges include a portion providing protection to the Vasconia local marker in Colombia.

The Company has the following commodity risk management contracts in place as of the date of this release:

Period		Type	Reference	Volume (bopd)		Contract Terms ($ per bbl)
					Purchased Put or Fixed Price	Sold Put	Sold Call
4Q2020		Zero cost 3-way	Brent	4,000	55.0	45.0	71.0-73.8
		Zero cost 3-way	Brent	2,000	55.0	45.0	65.2
		Zero cost 3-way	Brent	4,000	55.0	45.0	69.0-70.0
		Zero cost 3-way	Brent	1,000	55.0	45.0	71.95
		Zero cost collar	Brent	5,000	31.7-32.0	N/A	40.0-40.3
		Zero cost collar	Brent	5,000	35.0	N/A	49.8-51.3
		Zero cost collar	Brent	2,500	35.0	N/A	45.1
		Zero cost collar	Vasconia	2,000	30.0	N/A	44.2
		Zero cost collar	Brent	2,500	40.0	N/A	50.3-50.4
1Q2021		Zero cost collar	Brent	7,500	35.0	N/A	50.3-53.8
		Zero cost collar	Brent	2,000	40.0	N/A	53.5-53.9
		Zero cost collar	Brent	3,500	37.0	N/A	50.0
2Q2021		Zero cost collar	Brent	5,000	35.0	N/A	51.7-55.0
		Zero cost collar	Brent	3,500	38.0	N/A	51.0
		Zero cost collar	Brent	2,000	40.0	N/A	53.5-53.9
		Zero cost collar	Brent	2,500	40.0	N/A	50.3-50.4
3Q2021		Zero cost collar	Brent	2,000	40.0	N/A	56.0
		Zero cost collar	Brent	2,500	40.0	N/A	50.4-50.5
4Q2021		Zero cost collar	Brent	2,000	40.0	N/A	56.0
		Zero cost collar	Brent	2,500	40.0	N/A	50.4-50.5

For further details, please refer to Note 4 of GeoPark’s consolidated financial statements for the period ended September 30, 2020, available on the Company’s website.

SELECTED INFORMATION BY BUSINESS SEGMENT
(UNAUDITED)
Colombia (In millions of $)		3Q2020		3Q2019
Sale of crude oil		82.8		129.0
Sale of gas		0.5		0.5
Revenue		83.3		129.5
Production and operating costsa		-22.1		-28.2
Adjusted EBITDA		53.4		92.5
Capital expenditureb		9.7		15.4

Chile (In millions of $)		3Q2020		3Q2019
Sale of crude oil		1.2		2.3
Sale of gas		4.2		5.8
Revenue		5.3		8.1
Production and operating costsa		-2.0		-5.7
Adjusted EBITDA		2.7		1.3
Capital expenditureb		0.0		0.4

Brazil (In millions of $)		3Q2020		3Q2019
Sale of crude oil		0.1		0.2
Sale of gas		3.3		5.7
Revenue		3.4		5.9
Production and operating costsa		-0.6		-1.5
Adjusted EBITDA		1.9		2.7
Capital expenditureb		0.0		0.3

Argentina (In millions of $)		3Q2020		3Q2019
Sale of crude oil		5.3		6.7
Sale of gas		0.8		1.0
Revenue		6.1		7.7
Production and operating costsa		-3.8		-6.3
Adjusted EBITDA		0.4		-1.7
Capital expenditureb		0.0		4.0

a)		Production and operating costs = Operating costs + Royalties + Share-based payments.
b)		Capital expenditure in Peru and Ecuador explains the difference with the reported figure in the Key Performance Indicators table.

CONSOLIDATED STATEMENT OF INCOME
(UNAUDITED)
(In millions of $)		3Q2020		3Q2019		9M2020		9M2019
REVENUE
Sale of crude oil		89.3		138.2		262.2		434.6
Sale of gas		8.8		13.0		24.9		36.2
TOTAL REVENUE		98.1		151.2		287.0		470.9
Commodity risk management contracts		2.7		4.4		25.6		-16.0
Production and operating costs		-28.4		-41.7		-90.2		-126.7
Geological and geophysical expenses (G&G)		-2.8		-4.3		-10.2		-12.9
Administrative expenses (G&A)		-10.4		-14.5		-34.4		-39.5
Selling expenses		-1.3		-2.4		-4.9		-11.3
Depreciation		-26.7		-26.5		-89.3		-76.8
Write-off of unsuccessful exploration efforts		-0.6		-8.4		-3.8		-9.3
Impairment loss on non-financial assets		-1.0		-		-98.5		-
Other operating		-1.3		-1.4		-8.9		0.6
OPERATING (LOSS) PROFIT		28.5		56.4		-27.5		179.0
Financial costs, net		-15.8		-8.6		-45.0		-26.6
Foreign exchange gain (loss)		-0.7		0.8		-6.7		-0.7
(LOSS) PROFIT BEFORE INCOME TAX		12.0		48.5		-79.3		151.8
Income tax		-16.3		-41.8		-34.5		-93.9
(LOSS) PROFIT FOR THE PERIOD		-4.3		6.8		-113.7		57.9
Non‑controlling minority interest		-		-		-		-
ATTRIBUTABLE TO OWNERS OF GEOPARK		-4.3		6.8		-113.7		57.9

SUMMARIZED CONSOLIDATED STATEMENT OF FINANCIAL POSITION
(QUARTERLY INFORMATION UNAUDITED)
(In millions of $)	Sept '20		Dec '19
Non-Current Assets
Property, plant and equipment	716.8		567.8
Other non-current assets	60.4		58.4
Total Non-Current Assets	777.2		626.2
Current Assets
Inventories	11.9		11.4
Trade receivables	37.1		44.2
Other current assets	62.2		59.2
Cash at bank and in hand	163.7		111.2
Total Current Assets	274.9		225.9
Total Assets	1,052.1		852.1
Equity
Equity attributable to owners of GeoPark	4.0		132.9
Total Equity	4.0		132.9
Non-Current Liabilities
Borrowings	767.4		420.1
Other non-current liabilities	119.3		84.2
Total Non-Current Liabilities	886.7		504.3
Current Liabilities
Borrowings	4.8		17.3
Other current liabilities	156.6		197.6
Total Current Liabilities	161.4		214.9
Total Liabilities	1,048.1		719.2
Total Liabilities and Equity	1,052.1		852.1

SUMMARIZED CONSOLIDATED STATEMENT OF CASH FLOW
(QUARTERLY INFORMATION UNAUDITED)
(In millions of $)		3Q2020		3Q2019		9M2020		9M2019
Cash flow from operating activities		45.7		63.8		91.6		156.9
Cash flow (used in) investing activities		-9.8		-15.0		-321.6		-81.1
Cash flow (used in) from financing activities		-29.5		-35.9		284.2		-121.7

RECONCILIATION OF ADJUSTED EBITDA TO (LOSS) PROFIT BEFORE INCOME TAX
(UNAUDITED)
9M2020 (In millions of $)		Colombia		Chile		Brazil		Argentina		Other(a)		Total
Adjusted EBITDA		158.1		7.9		2.5		2.9		-9.8		161.6
Depreciation		-47.9		-25.2		-2.5		-13.3		-0.4		-89.3
Unrealized commodity risk management contracts		9.9		-		-		-		-		9.9
Write-off of unsuccessful exploration efforts & impairment		-		-53.5		-1.6		-16.2		-31.0		-102.3
Share based payment		-0.3		-0.1		-		-0.1		-5.4		-5.8
IFRS 16		4.6		0.1		1.6		0.7		0.3		7.3
Others		0.2		-0.5		-0.3		-1.8		-6.5		-8.8
OPERATING (LOSS) PROFIT		124.6		-71.3		-0.2		-27.9		-52.8		-27.5
Financial costs, net												-45.0
Foreign exchange charges, net												-6.7
LOSS BEFORE INCOME TAX												-79.3
9M2019 (In millions of $)		Colombia		Chile		Brazil		Argentina		Other(a)		Total
Adjusted EBITDA		281.5		5.8		7.5		2.8		-19.9		277.7
Depreciation		-34.3		-25.7		-5.1		-11.1		-0.6		-76.8
Unrealized commodity risk management contracts		-19.9		-		-		-		-		-19.9
Write-off of unsuccessful exploration efforts & impairment		-0.2		-		-		-9.0		-		-9.3
Share based payment		-0.4		-0.0		-0.1		-0.1		-0.9		-1.4
IFRS 16		1.5		0.1		1.6		0.7		0.4		4.3
Others		2.8		-0.9		0.5		0.1		2.0		4.4
OPERATING (LOSS) PROFIT		230.9		-20.7		4.5		-16.6		-19.0		179.0
Financial costs, net												-26.6
Foreign exchange charges, net												-0.7
LOSS BEFORE INCOME TAX												151.8

(a)

Includes Peru, Ecuador and Corporate.

OPERATING COSTS USED FOR ADJUSTED EBITDA CALCULATION
(UNAUDITED)
3Q2020		Colombia		Chile		Brazil		Argentina		Total
Operating costs ($mm)		15.1		1.8		0.3		2.8		19.9
IFRS 16 ($mm)		1.6		0.0		0.5		0.1		2.3
Operating costs - Adj. EBITDA ($mm)		16.7		1.8		0.8		2.9		22.2
Sales volume (mmboe)		2.9		0.3		0.1		0.2		3.5
Operating costs per boe – Adj. EBITDA		5.9		5.3		5.8		14.9		6.3

3Q2019		Colombia		Chile		Brazil		Argentina		Total
Operating costs ($mm)		15.1		5.4		1.0		5.1		26.6
IFRS 16 ($mm)		0.3		0.0		0.5		0.1		1.0
Operating costs - Adj. EBITDA ($mm)		15.4		5.4		1.5		5.2		27.6
Sales volume (mmboe)		2.8		0.3		0.2		0.2		3.4
Operating costs per boe – Adj. EBITDA		5.6		19.3		7.9		27.0		8.1

G&A AND G&G FOR ADJUSTED EBITDA CALCULATION
(UNAUDITED)
		3Q2020		3Q2019
Administrative Expenses ($mm)		10.4		14.5
Share-based payments ($mm)		-1.8		-0.3
IFRS 16 ($mm)		0.2		0.3
G&A Expenses - Adj. EBITDA ($mm)		8.7		14.5
Sales volume (mmboe)		3.5		3.4
G&A per boe - Adj. EBITDA		2.5		4.2
		3Q2020		3Q2019
Geological & Geophysical Expenses (G&G)		2.8		4.3
Share-based payments ($mm)		0.0		0.0
IFRS 16 ($mm)		0.1		0.2
Allocation to capitalized projects ($mm)		0.0		1.9
G&G Expenses - Adj. EBITDA ($mm)		2.8		6.3
Sales volume (mmboe)		3.5		3.4
G&G per boe - Adj. EBITDA		0.8		1.8

ENVIRONMENTAL, SOCIAL AND GOVERNANCE / SPEED UPDATE

New Independent Board Members - Effective August 1, 2020

Appointment of Silvia Escovar Gomez

Ms. Escovar, one of the most respected and admired business leaders in Latin America, brings with her a valuable mix of government, multilateral organization, and private enterprise experience, and a successful track record in each area. An economist by training, Ms. Escovar has previously worked for the World Bank, the Central Bank of Colombia and the National Department of Planning. She also served as Deputy Secretary of Education and Deputy Secretary of Finance for the Bogota municipal government.

Since 2012, Ms. Escovar has been the CEO of Terpel S.A. – a fuel distribution company. Under her leadership, Terpel became Colombia’s third largest company. Ms. Escovar is an innovator who led a team that converted and improved Terpel’s business model, expanding the range and quality of its services and enhancing its performance in the long-term. She and her team made Terpel a true leader in sustainability, with consistently high rankings in the RobecoSAM Sustainability Yearbook.

Ms. Escovar is also highly sought after in national discussions on policy, trade, diversity and inclusion. Ms. Escovar’s other Board memberships include Grupo Bancolombia and Organizacion Corona S.A.

Appointment of Somit Varma

Mr. Varma is a proven and respected investor in oil, gas, mining and infrastructure projects across the globe. His impressive track-record includes building management teams, growing businesses to scale and making significant contributions towards improving environmental, social and corporate governance standards. In addition, he has worked with governments and communities in Latin America, Asia and Africa to achieve better outcomes from the use of their natural resources.

Until 2010, Mr. Varma was the Global Head of Oil, Gas, Mining and Chemicals for the International Finance Corporation (“IFC”). From 2011 until July 2020, Mr. Varma was a Managing Director in the Energy Group at Warburg Pincus LLC, one of the world’s premier private equity firms with over $10 billion committed across a wide range of energy companies globally.

Mr. Varma is from New Delhi, India and earned his MBA at Boston University before attending the Executive Development Program at Harvard Business School.

CONFERENCE CALL INFORMATION

GeoPark management will host a conference call on November 5, 2020 at 10:00 am (Eastern Standard Time) to discuss the 3Q2020 results and the work program and investment guidelines for 2021.

To listen to the call, participants can access the webcast located in the Investor Support section of the Company’s website at www.geo-park.com, or by clicking below:

https://event.on24.com/wcc/r/2770543/D46DCDE802A42ABE385B37543F22E6FC

Interested parties may participate in the conference call by dialing the numbers provided below:

United States Participants: 866-547-1509
International Participants: +1 920-663-6208
Passcode: 2754509

Please allow extra time prior to the call to visit the website and download any streaming media software that might be required to listen to the webcast. An archive of the webcast replay will be made available in the Investor Support section of the Company’s website at www.geo-park.com after the conclusion of the live call.

GeoPark can be visited online at www.geo-park.com.

1		Operating costs per boe represent the figures used in Adjusted EBTIDA calculation as if IFRS 16 had not been adopted.
2		Brent price assumption from November to December 2020, using a Brent to Vasconia differential averaging $4 per bbl.
3		Operating costs per boe represents the figures used in Adjusted EBTIDA calculation, as if IFRS 16 had not been adopted.
4		Information per boe represents the figures used in Adjusted EBTIDA calculation, mainly excluding the effect of share-based payments and the effect of IFRS 16.
5		Information per boe represents the figures used in Adjusted EBTIDA calculation, excluding the effect of share-based payments and the effect of IFRS 16 and including amounts allocated to capitalized projects.
6		See “Reconciliation of Adjusted EBITDA to Profit (Loss) Before Income Tax and Adjusted EBITDA per boe” included in this press release.

GLOSSARY

Adjusted EBITDA	Adjusted EBITDA is defined as profit for the period before net finance costs, income tax, depreciation, amortization, the effect of IFRS 16, certain non-cash items such as impairments and write-offs of unsuccessful efforts, accrual of share-based payments, unrealized results on commodity risk management contracts and other non-recurring events
Adjusted EBITDA per boe	Adjusted EBITDA divided by total boe deliveries
Operating Netback per boe	Revenue, less production and operating costs (net of depreciation charges and accrual of stock options and stock awards, the effect of IFRS 16), selling expenses, and realized results on commodity risk management contracts, divided by total boe deliveries. Operating Netback is equivalent to Adjusted EBITDA net of cash expenses included in Administrative, Geological and Geophysical and Other operating costs
Bbl	Barrel
Boe	Barrels of oil equivalent
Boepd	Barrels of oil equivalent per day
Bopd	Barrels of oil per day
D&M	DeGolyer and MacNaughton
Free Cash Flow	Operating cash flow less cash flow used in investment activities
F&D costs	Finding and Development costs, calculated as capital expenditures divided by the applicable net reserve additions before changes in Future Development Capital
G&A	Administrative Expenses
G&G	Geological & Geophysical Expenses
Mboe	Thousand barrels of oil equivalent
Mmbo	Million barrels of oil
Mmboe	Million barrels of oil equivalent
Mcfpd	Thousand cubic feet per day
Mmcfpd	Million cubic feet per day
Mm3/day	Thousand cubic meters per day
PRMS	Petroleum Resources Management System
WI	Working interest
NPV10	Present value of estimated future oil and gas revenue, net of estimated direct expenses, discounted at an annual rate of 10%
Sqkm	Square kilometers

NOTICE

Additional information about GeoPark can be found in the “Investor Support” section on the website at www.geo-park.com.

Rounding amounts and percentages: Certain amounts and percentages included in this press release have been rounded for ease of presentation. Percentage figures included in this press release have not in all cases been calculated on the basis of such rounded figures, but on the basis of such amounts prior to rounding. For this reason, certain percentage amounts in this press release may vary from those obtained by performing the same calculations using the figures in the financial statements. In addition, certain other amounts that appear in this press release may not sum due to rounding.

This press release contains certain oil and gas metrics, including information per share, operating netback, reserve life index and others, which do not have standardized meanings or standard methods of calculation and therefore such measures may not be comparable to similar measures used by other companies. Such metrics have been included herein to provide readers with additional measures to evaluate the Company's performance; however, such measures are not reliable indicators of the future performance of the Company and future performance may not compare to the performance in previous periods.

CAUTIONARY STATEMENTS RELEVANT TO FORWARD-LOOKING INFORMATION

This press release contains statements that constitute forward-looking statements. Many of the forward- looking statements contained in this press release can be identified by the use of forward-looking words such as ‘‘anticipate,’’ ‘‘believe,’’ ‘‘could,’’ ‘‘expect,’’ ‘‘should,’’ ‘‘plan,’’ ‘‘intend,’’ ‘‘will,’’ ‘‘estimate’’ and ‘‘potential,’’ among others.

Forward-looking statements that appear in a number of places in this press release include, but are not limited to, statements regarding the intent, belief or current expectations, regarding various matters, including the Amerisur acquisition, the Covid-19 pandemic, cost reduction initiatives, expected or future production, production growth and operating and financial performance, operating netback per boe and capital expenditures plan. Forward-looking statements are based on management’s beliefs and assumptions, and on information currently available to the management. Such statements are subject to risks and uncertainties, and actual results may differ materially from those expressed or implied in the forward-looking statements due to various factors.

Forward-looking statements speak only as of the date they are made, and the Company does not undertake any obligation to update them in light of new information or future developments or to release publicly any revisions to these statements in order to reflect later events or circumstances, or to reflect the occurrence of unanticipated events. For a discussion of the risks facing the Company which could affect whether these forward-looking statements are realized, see filings with the U.S. Securities and Exchange Commission (SEC).

Oil and gas production figures included in this release are stated before the effect of royalties paid in kind, consumption and losses. Annual production per day is obtained by dividing total production by 365 days.

Information about oil and gas reserves: The SEC permits oil and gas companies, in their filings with the SEC, to disclose only proven, probable and possible reserves that meet the SEC's definitions for such terms. GeoPark uses certain terms in this press release, such as "PRMS Reserves" that the SEC's guidelines do not permit GeoPark from including in filings with the SEC. As a result, the information in the Company’s SEC filings with respect to reserves will differ significantly from the information in this press release.

NPV10 for PRMS 1P, 2P and 3P reserves is not a substitute for the standardized measure of discounted future net cash flow for SEC proved reserves.

The reserve estimates provided in this release are estimates only, and there is no guarantee that the estimated reserves will be recovered. Actual reserves may eventually prove to be greater than, or less than, the estimates provided herein. Statements relating to reserves are by their nature forward-looking statements.

Non-GAAP Measures: The Company believes Adjusted EBITDA, free cash flow and operating netback per boe, which are each non-GAAP measures, are useful because they allow the Company to more effectively evaluate its operating performance and compare the results of its operations from period to period without regard to its financing methods or capital structure. The Company’s calculation of Adjusted EBITDA, free cash flow, return on capital employed and operating netback per boe may not be comparable to other similarly titled measures of other companies.

Adjusted EBITDA: The Company defines Adjusted EBITDA as profit for the period before net finance costs, income tax, depreciation, amortization and certain non-cash items such as impairments and write-offs of unsuccessful exploration and evaluation assets, accrual of stock options stock awards, unrealized results on commodity risk management contracts and other non-recurring events. Adjusted EBITDA is not a measure of profit or cash flow as determined by IFRS. The Company excludes the items listed above from profit for the period in arriving at Adjusted EBITDA because these amounts can vary substantially from company to company within our industry depending upon accounting methods and book values of assets, capital structures and the method by which the assets were acquired. Adjusted EBITDA should not be considered as an alternative to, or more meaningful than, profit for the period or cash flow from operating activities as determined in accordance with IFRS or as an indicator of our operating performance or liquidity. Certain items excluded from Adjusted EBITDA are significant components in understanding and assessing a company’s financial performance, such as a company’s cost of capital and tax structure and significant and/or recurring write-offs, as well as the historic costs of depreciable assets, none of which are components of Adjusted EBITDA. For a reconciliation of Adjusted EBITDA to the IFRS financial measure of profit for the year or corresponding period, see the accompanying financial tables.

Operating Netback per boe: Operating netback per boe should not be considered as an alternative to, or more meaningful than, profit for the period or cash flow from operating activities as determined in accordance with IFRS or as an indicator of the Company’s operating performance or liquidity. Certain items excluded from operating netback per boe are significant components in understanding and assessing a company’s financial performance, such as a company’s cost of capital and tax structure and significant and/or recurring write-offs, as well as the historic costs of depreciable assets, none of which are components of operating netback per boe. The Company’s calculation of operating netback per boe may not be comparable to other similarly titled measures of other companies. For a reconciliation of operating netback per boe to the IFRS financial measure of profit for the year or corresponding period, see the accompanying financial tables.

Net Debt: Net debt is defined as current and non-current borrowings less cash and cash equivalents.